Surface controlled subsurface safety valve having integral pack-off

ABSTRACT

A safety valve apparatus has a housing with a bore and a projection in the bore. A flapper rotatably disposed on the housing is movable relative to the bore between opened and closed positions, and a packing element disposed on the housing is compressible to engage an inner conduit wall surrounding the housing. An upper sleeve disposed within the bore above the projection is hydraulically movable from a first position to a second position via the hydraulic communication with a port in the projection. The first sleeve when moved to the second position compresses the packing element. A piston disposed in the housing hydraulically communicates with the port and couples to a second sleeve disposed within the bore below the projection. The second sleeve conceals the piston and is hydraulically movable via the hydraulic communication of the port with the piston to open and close the flapper.

CROSS-REFERENCE TO RELATED APPLICATIONS

This application is filed concurrently with U.S. patent application Ser.No. 12/128,790, filed 29 May 2008, and entitled “Retrievable SurfaceControlled Subsurface Safety Valve” by Jean-Luc Jacob, Rodger Lacy,Richard Jones, & Stuart Dennistoun, which is incorporated herein byreference in its entirety.

BACKGROUND

When an existing safety valve in a well becomes inoperable, operatorsmust take measures to rectify the problem by either working over thewell to install an entirely new safety valve on the tubing or deployinga safety valve within the existing tubing. In the past, operators mayhave simply deployed a subsurface controlled subsurface safety valve inthe well. The subsurface controlled valves could be a velocity valve orProtected Bellows (PB) pressure actuated valve. However, regulatoryrequirements and concerns over potential blowout have prompted operatorsto work over the well rather than deploying such subsurface controlledvalves. As expected, working over a well can be time consuming andexpensive. Therefore, operators would prefer to deploy a surfacecontrolled safety valve in the tubing of the well without having to workover the well.

Current technology primarily allows surface controlled safety valves tobe deployed in wells that have either an existing tubing-mounted safetyvalve or a tubing-mounted safety valve landing nipple. In French PatentNo. FR 2734863 to Jacob Jean-Luc, for example, a surface controlledsafety valve device 100 is disclosed that can be landed in an existinglanding nipple from which the original safety valve has been removed.This safety valve device 100 reproduced in FIGS. 1A-1B is set in thelanding nipple 10 using a special adapter 160 that mechanically hold thelocking dogs 102 and the flapper 104 of the device 100 until the device200 can be properly positioned in the landing nipple 10. Then, whenreleasing the device 100, the adapter 160 must disengage from the device100 so that the locking dogs 102 engage the nipple 10 whilesimultaneously letting the flapper 104 close. Moreover, these steps mustbe performed while not damaging a hydraulic connector 120 andintermediate tubing 130 exposed in the device 100 adjacent to where thespecial adapter 160 holds the device 200.

When deployed in the landing nipple 10, a conduit (not shown)communicated through the tubing connects to the device 100 to operatethe flapper 104. This conduit conveys hydraulic fluid to the connector120 connected to a fixed portion 123 in the device 100. This fixedportion 123 in turn communicates the fluid to the intermediate tubing130 that is movable in the fixed portion 123. A cross port 132 from theintermediate tubing 130 communicates the fluid so that it fills a space133 and moves a sleeve 134 connected to the intermediate tubing 130. Asthe sleeve 134 moves down against the bias of a spring, it opens theflapper 104. Because the mechanisms for operating the device 100 areexposed and involve several moving components, the mechanical operationof this device 100 is less than favorable. Moreover, the exposedmechanisms that operate the device 100 with their several moving partscan become damaged.

In U.S. Pat. No. 7,040,409 to Sangla, another safety valve device forwells is disclosed that can be deployed in tubing without the need foran existing landing nipple. This device 200 is reproduced in FIGS.2A-2B. As shown in FIG. 2B, the lower part of the device 200 has aflapper 210 that closes by a spring (not shown) and opens by a sleeve212 under the thrust action of a ring 214 connected to a piston 216.With sufficient hydraulic pressure in a valve opening chamber 218, thepiston 216 and ring 214 press the sleeve 212 against the bias of thespring 213 so that the sleeve 212 slides down and opens the flapper 210.With the flapper 210 open, a passage 202 in the device 200 permits fluidcommunication through the device 200. In the absence of pressure in thechamber 218, the spring 213 pushes the sleeve 212 upwards so that theflapper 210 closes.

To position the device 200 in tubing 20, the lower part of the device200 as shown in FIG. 2B has lower anchor dogs 220 a. These lower dogs220 a are displaced radially by a lower piston 222 a whose end has theshape of a cone on which the lower dogs 220 a rest. The lower piston 222a is pushed under the lower dogs 220 a by the hydraulic pressure in alower anchor chamber 224 a so that the displacement of the lower piston222 a locks the lower dogs 220 a on the wall of tubing 20. Locks 226 a,such as dog stops or teeth, hold the lower piston 222 a in place evenwhen the pressure has dropped in lower chamber 224 a. The upper part ofthe device 200 as shown in FIG. 2A similarly has upper anchor dogs 220b, piston 222 b, hydraulic chamber 224 b, and locks 226 b.

To create a seal in the tubing 20, the device 200 uses a pile of eightcups 230 that position between the device 200 and the tubing 20. Thesecups 230 have a general herringbone U or V shape and are symmetricallyarranged along the device's central axis. Hydraulic pressure present ina sealing assembly chamber 234 displaces a piston 232 that activates thecups 230 against the tubing 20. Locks 236 hold this piston 232 in placeeven without pressure in the chamber 234.

Hydraulic pressure communicated from the surface operates the device200. In particular, rods (not shown) from the surface connect to aconnector 240 that communicates with internal line 242. This internalline 242 communicates with an interconnecting tube 250 to distributehydraulic pressure to the valve opening chamber 234 via a cross port243, to the anchor chamber 224 a-b via cross ports 244 a-b, and to thesealing assembly chamber 218 via the tube 250. A hydraulic pressure risein line 242 transmits the pressure to all these chambers simultaneously.When the hydraulic pressure drops in line 242, the device 200 closes butremains in position, anchored and sealed. A special profile 204 arrangedat the top of the device 200 can be used to unanchor the device 200 bytraction and jarring with a fishing tool suited to this profile 202. Byjarring on the device 200, a series of shear pins are broken, thusreleasing anchor pistons 222 a-b and the sealing piston 232. Thereleased device 200 can then be pulled up to the surface.

As with the valve 100 of FIGS. 1A-1B, the valve 200 of FIGS. 2A-2B alsohas features that are less than ideal. First, the pile of cups 230offers less than desirable performance to hold the device 200 in tubing20. In addition, the intricate arrangement and number of componentsincluding line 242; cross ports 243 and 244 a-b; tube 250; multiplechambers 218, 224 a-b, and 234; multiple pistons 216, 222 a-b, and 232;and exposed rod 216 make the device 200 prone to potential damage andmalfunction and further make manufacture and assembly of the device 200difficult and costly.

Accordingly, a need exists for more effective subsurface safety valvesthat can be deployed in a well.

BRIEF DESCRIPTION OF THE DRAWINGS

FIGS. 1A-1B illustrate a surface controlled subsurface safety valveaccording to the prior art.

FIGS. 2A-2B illustrate another surface controlled subsurface safetyvalve according to the prior art.

FIG. 3 illustrates a cross-section of a retrievable surface controlledsubsurface safety valve according to one embodiment of the presentdisclosure.

FIG. 4 illustrates an example of male and female members of a preferredquick connector for use with the disclosed valves.

FIG. 5A illustrates a detailed cross-section of an upper portion of thevalve in FIG. 3.

FIG. 5B illustrates a detailed cross-section of a lower portion of thevalve in FIG. 3.

FIG. 6 illustrates a cross-section of a retrievable surface controlledsubsurface safety valve according to another embodiment of the presentdisclosure.

FIG. 7A illustrates a detailed cross-section of an upper portion of thevalve in FIG. 6.

FIG. 7B illustrates a detailed cross-section of a lower portion of thevalve in FIG. 6.

FIGS. 8A-8D illustrate cross-sectional views of a wellhead assembly invarious stages of deploying the surface controlled safety valve of FIG.6.

FIG. 9A is a detailed cross-section of a capillary hanger of theassembly of FIGS. 8A-8D.

FIG. 9B is a top view of the capillary hanger of FIG. 9A.

FIG. 10 is a cross-sectional view of another wellhead assembly fordeploying a surface controlled safety valve according to the presentdisclosure.

DETAILED DESCRIPTION

As disclosed herein, a surface controlled subsurface safety valveapparatus can be installed in a well that either has or does not haveexisting hardware for a surface controlled valve. Coil tubingcommunicates the hydraulic fluid to the apparatus to operate the valve.One disclosed valve apparatus deploys in a well that has an existingsafety valve nipple and is retrievable therefrom. Another disclosedvalve apparatus deploys in tubing of a well with or without a safetyvalve nipple.

I. Retrievable Surface Controlled Subsurface Safety Valve

A retrievable surface controlled subsurface safety valve 300 illustratedin FIG. 3 installs in a well having existing hardware for a surfacecontrolled valve and can be deployed in the well using standard wirelineprocedures. When run in the well, the valve 300 lands in the existinglanding nipple 50 after the inoperable safety valve has been removed.

The safety valve 300 has a housing 302 with a landing portion 310 and asafety valve portion 360. The landing portion 310 best shown in FIG. 5Ahas locking dogs 332 movable on the housing 302 between engaged anddisengaged positions. In the engaged position, for example, the lockingdogs 332 engage a groove 52 in the surrounding landing nipple 50 to holdthe valve 300 in the nipple 50. The valve portion 360 best shown in FIG.5B has a flapper 390 rotatably disposed on the housing 302. The flapper390 rotates on a pivot pin 392, and a torsion spring 394 biases theflapper 390 to a closed position.

To operate the landing portion 310, an upper sleeve 320 shown in FIG. 5Amovably disposed within the housing 302 can be mechanically movedbetween upper and lower locked positions against the bias of a spring324. In the upper locked position as shown in FIG. 5A, the upper sleeve320's distal end 326 moves the locking dogs 332 to the engaged positionso that they engage the landing nipple's groove 52. Although not shown,the upper sleeve 320 can be mechanically moved to a lower position thatpermits the locking dogs 332 to move to the disengaged position freefrom the groove 52.

To operate the valve portion 360, a lower sleeve 380 shown in FIG. 5Bmovably disposed within the housing 302 can be hydraulically moved froman upper position to a lower position against the bias of a spring 386.When hydraulically moved to the lower position (not shown), the sleeve380 moves the flapper 390 open. In the absence of sufficient hydraulicpressure, however, the bias of the spring 386 moves the sleeve 380 tothe upper position shown in FIG. 5B, permitting the flapper 390 to closeby its own torsion spring 394 about its pivot pin 392.

With a basic understanding of the operation of the valve 300, discussionnow turns to a more detailed discussion of its components and operation.

A. DEPLOYING THE VALVE

In deploying the valve 300, a conventional wireline tool (not shown)couples to the profile in the upper end of the valve's housing 302 andlowers the valve 300 to the landing nipple 50. While it is run downhole,trigger dogs 322 on the upper sleeve 320 remain engaged in lower grooves312 in the housing 302, while the upper sleeve 320 allows the lockingdogs 332 to remain disengaged. When in position, the tool actuates thelanding portion 310 by moving the upper sleeve 320 upward against thebias of spring 324 and disengaging the trigger dogs 322 from the lowergrooves 312 so they engage upper grooves 314. With the upward movementof the sleeve 320, the sleeve's distal end 326 pushes out the lockingdogs 332 from the housing 302 so that they engage the landing nipple'sgroove 52 as shown in FIG. 5A. Once landed, upper and lower chevrons340/342 on the housing 302 also seal above and below the existing port54 in the landing nipple 50 provided for the removed valve.

B. OPERATING THE FLAPPER ON THE VALVE

With the valve 300 landed in the nipple 50, operators lower a capillarystring 304 down hole to the valve. This capillary string 304 can be hungfrom a capillary hanger (not shown) at the surface. The capillary string304 may include blade centralizers 305 to facilitate lowering the string304 downhole. The string 304's distal end passes into the valve'shousing 302, and a hydraulic connector 350 is used to couple the string304 to the valve 300. In particular, a female member 352 of thehydraulic connector 350 on the distal end mates with a male member 354on the valve 300.

Briefly, FIG. 4 shows one example of a connector 350 that can be usedwith the valves of the present disclosure. The connector 350 can be anautomatic connector from Staubli of France. The male member 354 can havepart no. N01219806, and the female member 352 can have part no.N01219906. The connector 350 can an exterior pressure rating of about350 Bar, an interior pressure rating of 550 Bar when coupled, a couplingforce of 25 Kg, and a decoupling force of 200 Kg.

Once the members 352/354 are connected as shown, the capillary string304 communicates with an internal port 372 defined in a projection 370within the valve 300 as shown in FIG. 5B. Operators then injectpressurized hydraulic fluid through the capillary string 304. As thefluid reaches the internal port 372, it fills the annular space 375surrounding the projection 370.

From the annular space 375, the fluid reaches a passage 365 in the valveportion 360 and engages an internal piston 382. Hydraulic pressurecommunicated by the fluid moves this piston 382 downward against thebias of a spring 386 at the piston's end 384. The downward moving end384 moves the inner sleeve 380 connected thereto so that the innersleeve 380 forces open the flapper 390. In this way, the valve portion360 can operate in a conventional manner. As long as hydraulic pressureis supplied to the piston 382 via the capillary string 304, for example,the inner sleeve 380 maintains the flapper 390 open, thereby permittingfluid communication through the valve's housing 302. When hydraulicpressure is released due to an unexpected up flow or the like, thespring 386 moves the inner sleeve 380 away from the flapper 390, and theflapper 390 is biased shut by its torsion spring 394, thereby sealingfluid communication through the valve's housing 302.

C. RETRIEVING THE VALVE

Retrieval of the valve 300 can be accomplished by uncoupling thehydraulic connector 350 and removing the capillary string 304. Then, aconventional wireline tool can engage the profile in valve's upper end,disengage the locking dogs 332 from the nipple's slot 52, and pull thevalve 300 up hole.

D. ADVANTAGES

As opposed to prior art subsurface controlled safety valves, thedisclosed valve 300 has a number of advantages, some of which arehighlighted here. In one advantage, the valve 300 deploys in a way thatlessens potential damage to the valve's components, such as the malemember 354 and movable components. In addition, communication ofhydraulic fluid to the safety valve portion 360 is achieved using anintermediate projection 370 and a single port 372 communicating with anannular space 375 and piston 382 without significantly obstructing theflow passage through the valve 300. Furthermore, operation of the valveportion 360 does not involve a number of movable components exposedwithin the flow passage of the valve 300, thereby reducing potentialdamage to the valve portion 360.

II. Subsurface Safety Valve with Integral Pack Off

The previous embodiment of safety valve 300 lands into an existinglanding nipple 50 downhole. By contrast, a surface controlled subsurfacesafety valve 400 in FIG. 6 installs in a well that does not necessarilyhave existing hardware for a surface controlled valve. Here, the valve400 has a hydraulically-set packer/pack-off portion 410 and a safetyvalve portion 460 that are both set simultaneously using hydraulicpressure from a safety valve control line.

For the pack-off portion 410, the valve 400 has a packing element 420and slips 430 disposed thereon. The packing element 420 is compressiblefrom an uncompressed condition to a compressed condition in which theelement 420 engages an inner wall of a surrounding conduit (not shown),such as tubing or the like. The slips 430 are movable radially from thehousing 402 from disengaged to engaged positions in which they contactthe surrounding inner conduit wall. The slips 430 can be retained by acentral portion (not shown) of a cover 431 over the slips 430 and may bebiased by springs, rings or the like.

For the valve portion 460, the valve 400 has a flapper 490 rotatablydisposed on the housing 402 by a pivot pin 492 and biased by a torsionspring 494 to a closed position. The flapper 3490 can move relative tothe valve's internal bore between opened and closed positions to eitherpermit fluid communication through the valve's bore 403 or not.

To operate the packer portion 410, hydraulic fluid moves an upper sleeve440 moves within the housing's bore. In one position as shown in FIG.7A, for example, the upper sleeve 440 leaves the packing element 420 inthe uncompressed condition. However, when the upper sleeve 440 ishydraulically moved to a lower position, the sleeve 440's movementcompresses the packing element 420 into a compressed condition so as toengage the inner conduit wall.

To operate the valve portion 460, a lower sleeve 480 shown in FIG. 7Bmovably disposed within the housing 402 can be hydraulically moved froman upper position to a lower position against the bias of a spring 486.When hydraulically moved to the lower position (not shown), the sleeve480 moves the flapper 490 open. In the absence of sufficient hydraulicpressure, the bias of the spring 486 moves the sleeve 480 to the upperposition, permitting the flapper 490 to close.

With a basic understanding of the operation of the valve 400, discussionnow turns to a more detailed discussion of its components and operation.

A. DEPLOYING THE VALVE

The valve 400 is run in the well using capillary string technology. Forexample, a capillary string 404 connects inside the valve housing 400with a hydraulic connector 450 having both a male member 454 and femalemember 452 similar to that disclosed in FIG. 3. The valve 400 is thenlowered by the capillary string 404 to a desired position downhole, andthe string 404 is hung from a capillary hanger (not shown) at thesurface. The capillary hanger preferably installs in a wellhead adapterat the wellhead tree. The hanger preferably locks into the gap betweenthe flange of the hanger bowl and the flange of the tree supportedabove. The hanger seals in the body of the tree using self-energizingpacking and is accessed by drilling and tapping the tree.

Once positioned, both the packer portion 410 and the safety valveportion 460 are hydraulically set by control line pressure communicatedvia the capillary string 404. In particular, the capillary string 404communicates with the sleeve's internal port 472 defined in a projection470 positioned internally in the housing 402. Operators then injectpressurized hydraulic fluid through the capillary string 404. When thefluid reaches the internal port 472 as shown in FIG. 7B, it fills theannular space 475 surrounding the projection 470.

From the intermediate annular space 475, the fluid communicates via anupper passage 445 to an upper annular space 444 near the upper slidingsleeve 440. As discussed below, fluid communicated via this passage 445operate the valve's packer portion 410. From the intermediate annularspace 475, the fluid also communicates via a lower passage 465 in thevalve portion 460 and engages a piston 480. As discussed below, fluidcommunicated via this passage 465 operates the valve portion 460.

B. HYDRAULICALLY OPERATING THE PACK OFF

In operating the valve's packer portion 410, the fluid communicated byupper passage 445 fills the upper annular space 444 which is best shownin FIG. 7B. Trapped by sealing member 446, the fluid increase the sizeof the space 444 and pushes against the sleeve 440's surrounding rib442, thereby forcing the sleeve 440 downward. As the sleeve 440 movesdownward, it moves an upper member 422 connected at the sleeve 440'supper end toward a lower member 424 disposed about the sleeve 440. Thesemembers 422/424 compress the packer element 420 between them so that itbecomes distended and engages an inner conduit wall (not shown)surrounding it. As preferred, this packing element 420 is a solid bodyof elastomeric material to create a fluid tight seal between the housingand the surrounding conduit.

As the sleeve 440 moves downward, it moves not only upper and lowermembers 422/424 but also moves an upper wedged member 432 toward a lowerwedged member 434 fixed to lower housing members 440 and 442. As thesleeve 440 moves downward, therefore, the wedged members 432/434 pushthe slips 430 outward from the housing 402 to engage the inner conduitwall (not shown) surrounding the housing 302. Eventually, as the sleeve440 is moved downward, outer serrations or grooves 441 on the sleeve 440engage locking rings 443 positioned in the housing 402 to prevent thesleeve 440 from moving upward.

C. HYDRAULICALLY OPERATING THE FLAPPER

Simultaneously, the communicated hydraulic fluid operates the safetyvalve portion 460. Here, hydraulic pressure communicated by the fluidvia passage 465 moves the piston 482 downward against the bias of spring486. The downward moving piston 482 also moves the inner sleeve 480,which in turn forces open the rotatable flapper 490 about its pin 392.In this way, the valve portion 460 can operate in a conventional manner.When hydraulic pressure is released due to an unexpected up flow or thelike, the spring 486 moves the inner sleeve 484 away from the flapper490, and the flapper 490 is biased shut by its torsion spring 494.

D. RETRIEVING THE VALVE

Retrieval of the safety valve 400 can use the capillary string 404.Alternatively, retrieval can involve releasing the capillary string 404and using standard wireline procedures to pull the safety valve 400 fromthe well in a manner similar to that used in removing a downhole packer.

E. ADVANTAGES

As opposed to the prior art surface controlled subsurface safety valves,the disclosed valve 400 has a number of advantages, some of which arehighlighted here. In one advantage, the valve 400 uses a solid packingelement and slip combination to produce the pack-off in the tubing. Thisproduces a more superior seal than found in the prior art which uses apile of packing cups. Second, the flapper 490 of the valve 400 isoperated using an annular rod piston arrangement with the componentsconcealed from the internal bore of the valve 400. This produces a morereliable mechanical arrangement than that found in the prior art whererod, piston, and tubing connections are exposed within the internal boreof the prior art valve. Third, the packing element 420 and the rodpiston 482 in the valve are actuated via hydraulic fluid from one port472 communicating with the coil tubing 404. This produces a simpler,more efficient communication of the hydraulic fluid as opposed to themultiple cross ports and chambers used in the prior art.

Finally, the disclosed valve 400 can be deployed using a capillarystring or coil tubing ranging in size from 0.25″ to 1.5″ and can beretrieved by either the capillary string or by standard wirelineprocedures. Deploying the valve 400 (as well as valve 300 of FIG. 3) canuse a capillary hanger that installs in a wellhead adapter at thewellhead tree and that locks into the gap between the flange of thehanger bowl and the flange of the tree supported above. This capillaryhanger preferably seals in the body of the tree using self-energizingpacking and is accessed by drilling and tapping the tree.

For example, FIGS. 8A-8D show a wellhead assembly 500 in various stagesof deploying a surface controlled safety valve (not shown), such asvalve 400 of FIG. 6. As shown in FIG. 8A, the assembly 500 includes anadapter 530 that bolts to the flange of a wellhead's hanger bowl 510 andthat supports a spool, valve or one or more other such tree component540 thereabove. A tubing hanger 520 positioned in the hanger bowl 510seals with the adapter 530 and supports tubing (not shown) downhole. Itis understood that the wellhead assembly 500 will have additionalcomponents that are not shown.

Initially, the surface controlled safety valve (400; FIG. 6) isinstalled downhole using capillary string procedures so that the valveseats in the downhole tubing according to the techniques discussedpreviously. The length of capillary string used to seat the valve can bemeasured for later use. After removing the capillary string and leavingthe seated valve, operators may install a packer downhole as a secondarybarrier. Then, operators drill and tap the adapter 530 with a controlline port 532 and one or more retention ports 534 that communicate withthe adapter's central bore. These ports 532 and 534 are offset from oneanother.

As shown in FIG. 8B, operators then install a capillary hanger 600through the tree component 540 using a seating element 602 that threadsinternally in the hanger 600. FIGS. 9A-9B show detailed views of thecapillary hanger 600. Once installed, the hanger 600 seats on the tubinghanger 520, but the side port (632; FIG. 9A-9B) on the hanger 600 isoffset a distance C from the control line port 532. Operators measurethe point where the control line port 532 aligns with the hanger 600 anduse this measurement to determine what length at the end of the hanger600 must be cut off so that the hanger's side port (632; FIG. 9A) canalign with the control line port 532.

As shown in FIG. 8C, the excess on the end of the hanger 600 is removed,and operators secure a downhole control line 550 to the central controlline port (630; FIGS. 9A-9B) on the hanger 600. Then, operators pass thecontrol line 550 through the spool 540, adapter 530, tubing hanger 520,and head 510 and seat the capillary hanger 600 on the tubing hanger 520.With the hanger 600 seated, a quick connector (not shown) on the end ofthe control line 550 makes inside the safety valve (not shown) downholeaccording to the techniques described above. With the hanger 600 seated,upper and lower seals within the hanger's grooves (636; FIG. 9A) sealinsides the adapter 530 above and below the ports 534 and 536 to sealthe capillary hanger 600 in the assembly 500.

Finally, as shown in FIG. 8D, operators insert and lock one or moreretention rods 560 in the one or more retention ports 534 so that theyengage in the peripheral slot (634; FIGS. 9A-9B) around the hanger 600to hold the hanger 600 in the adapter 530. With the hanger 600 secured,operators connect a fitting and control line 570 to the control lineport 532 on the adapter 530 so the downhole safety valve can behydraulically operated via the capillary string 550. Eventually, theseating element 600 can be removed from the capillary hanger 600 so thatfluid can pass through axial passages (620; FIGS. 9A-9B) in the hanger600.

Another alternative for deploying the surface controlled safety valve(400; FIG. 6) can use one of the hanger and wellhead arrangementsdisclosed in U.S. application Ser. No. 11/925,498, which is incorporatedherein by reference. As shown in FIG. 10, for example, a wellheadarrangement 700 has a hanger bowl 710 and tubing hanger 720. A capillarystring 740 connects to the downhole valve (not shown) and to the bottomend of the tubing hanger 720. Fluid communication with the string 740 isachieved by drilling and tapping a connection 730 in the hanger bowl 710that communicates with a side port in the tubing hanger 720.

The foregoing description of preferred and other embodiments is notintended to limit or restrict the scope or applicability of theinventive concepts conceived of by the Applicants. In exchange fordisclosing the inventive concepts contained herein, the Applicantsdesire all patent rights afforded by the appended claims. Therefore, itis intended that the appended claims include all modifications andalterations to the full extent that they come within the scope of thefollowing claims or the equivalents thereof.

1. A safety valve apparatus, comprising: a housing defining a bore andhaving a projection disposed in the bore, the projection having a portwith a first end communicating with the bore; a flapper rotatablydisposed on the housing and movable relative to the bore between openedand closed positions; a packing element disposed on the housing andbeing compressible from an uncompressed condition to a compressedcondition, the packing element in the compressed condition engagablewith an inner conduit wall surrounding the housing; a first sleevedisposed within the bore above the projection and being hydraulicallymovable from a first position to a second position via hydrauliccommunication with the port, the first sleeve in the first positionleaving the packing element in the uncompressed condition, the firstsleeve in the second position compressing the packing element into thecompressed condition; and a piston disposed in the housing andhydraulically communicating with the port; and a second sleeve disposedwithin the bore below the projection, the second sleeve coupled to andconcealing the piston and being hydraulically movable between third andfourth positions via hydraulic communication of the port with thepiston, the second sleeve in the third position moving the flapper tothe opened position, the second sleeve in the fourth position permittingthe flapper to move to the closed position.
 2. The apparatus of claim 1,further comprising a male member of a hydraulic connector disposed inthe bore of the housing and connected to the first end of the port. 3.The apparatus of claim 2, further comprising a female member of thehydraulic connector connecting to a capillary string, the female memberdisposable in the bore and mateable with the male member.
 4. Theapparatus of claim 1, wherein the housing comprises an intermediate bodyhaving the projection and disposed in the bore of the housing, the portin the projection having a second end communicating with an annularspace between the housing and the intermediate body.
 5. The apparatus ofclaim 4, wherein the annular space hydraulically communicates with thepiston coupled to the second sleeve.
 6. The apparatus of claim 5,wherein the annular space hydraulically communicates with anotherannular space between the housing and an annular rib on the firstsleeve.
 7. The apparatus of claim 1, further comprising at least oneslip disposed about the first sleeve and movable away from the housingvia the movement of the first sleeve from the first position to thesecond position, the at least one slip when moved away from the housingbeing engagable with the inner conduit wall surrounding the housing. 8.The apparatus of claim 1, further comprising a lock disposed about thefirst sleeve and locking the first sleeve in the second position.
 9. Theapparatus of claim 1, further comprising a spring disposed about thesecond sleeve and between the second sleeve and the housing, the springbiasing the second sleeve to the second position.
 10. The apparatus ofclaim 1, wherein the flapper is rotatable on a pin disposed on thehousing and is biased to the closed position by a torsion springdisposed on the pin.
 11. The apparatus of claim 1, wherein the firstsleeve comprises: a first compressing body attached about the firstsleeve on one side of the packing element; and a second compressing bodydisposed about the first sleeve on an opposite side of the packingelement and being movable relative to the first compressing body on thefirst sleeve.
 12. The apparatus of claim 11, further comprising: a firstwedged body disposed about the first sleeve and attached to the housing;at least one slip disposed about the first sleeve and having first andsecond wedged ends and an outer face, the first wedged end adjacent thefirst wedged body; and a second wedged body disposed about the firstsleeve between the second compressing body and the second wedged end ofthe at least one slip, the second wedged body being movable relative tothe first wedged body by the movement of the second compressing body.13. The apparatus of claim 1, wherein the packing element comprises asolid deformable material.
 14. The apparatus of claim 13, wherein thepacking element comprises an elastomeric material.
 15. A safety valveapparatus, comprising: a housing defining a bore; an intermediate bodydisposed in the bore, the intermediate body having an internal passagecommunicating with the bore and having a projection disposed in theinternal passage, the projection having a port, the port having a firstend communicating with the bore and having a second end communicatingwith an annular space between the intermediate body and the housing; apacking element disposed on the housing, the packing element beingcomposed of a solid deformable material and being compressible from anuncompressed condition to a compressed condition, the packing element inthe compressed condition engagable with an inner conduit wallsurrounding the housing; a first sleeve disposed within the bore abovethe projection and being hydraulically movable from a first position toa second position via hydraulic communication with the port and theannular space, the first sleeve in the first position leaving thepacking element in the uncompressed condition, the first sleeve in thesecond position compressing the packing element into the compressedcondition; at least one slip disposed about the first sleeve and movableaway from the housing via the movement of the first sleeve from thefirst position to the second position, the at least one slip moved whenaway from the housing being engagable with the inner conduit wallsurrounding the housing; a piston disposed in the housing andhydraulically communicating with the port; and a second sleeve disposedwithin the bore below the projection, the second sleeve coupled to andconcealing the piston and being hydraulically movable between third andfourth positions via hydraulic communication of the port and the annularspace with the piston, the second sleeve in the third position movingthe flapper to the opened position, the second sleeve in the fourthposition permitting the flapper to move to the closed position.
 16. Asafety valve apparatus, comprising: a housing defining a bore; meansdisposed within the housing for hydraulically communicating an annularspace disposed within the housing with a solitary port exposed to thebore; first means movably disposed on the housing for engaging anddisengaging from an inner conduit wall surrounding the housing; secondmeans being movable via hydraulic communication of the annular spacewith the solitary port for moving the first means; third means movablydisposed on the housing for opening and closing fluid communicationthrough the bore; and fourth means being movable via hydrauliccommunication of the annular space with the solitary port for moving thethird means.
 17. A method of deploying a safety valve in a well,comprising: deploying a safety valve in a conduit of a well using acapillary string coupled to a solitary port within the valve;communicating hydraulic fluid to the solitary port of the safety valvevia the capillary string; and engaging a solid deformable packingelement on the safety valve within the conduit by actuating the packingelement with the communicated hydraulic fluid; and opening a biasedflapper within the safety valve by actuating the flapper with thecommunicated hydraulic fluid simultaneously with the actuation of thepacking element.
 18. The method of claim 17, wherein actuating thepacking element and the flapper comprises communicating the hydraulicfluid from the capillary string via the solitary port to both a firstmovable sleeve engaging the packing element and a second movable sleeveengaging the flapper.
 19. The method of claim 17, wherein deploying thesafety valve comprises: coupling a first end of the capillary string tothe solitary port within the valve, and coupling a second end of thecapillary string on a capillary hanger.
 20. The method of claim 19,wherein deploying the safety valve comprises landing the capillaryhanger in a tubing hanger at the wellhead.
 21. The method of claim 20,wherein deploying the safety valve comprises communicating a first portin the capillary hanger with a second port tapped at the wellhead. 22.The method of claim 21, wherein deploying the safety valve comprises:inserting a retention rod in a third port tapped at the wellhead, andengaging an end of the retention rod in an external pocket on thecapillary hanger.
 23. A method of deploying a safety valve in a well,comprising: deploying a safety valve downhole from a wellhead using acapillary string; removing the capillary string from the safety valveand the wellhead; tapping a first cross port in the wellhead; attachinga capillary string to a capillary hanger; conveying the capillary stringthrough the wellhead; mating a distal end of the capillary string to thesafety valve downhole; landing the capillary hanger in the wellhead; andaligning a side port on the capillary hanger with the first cross port,the side port communicating with the capillary string.
 24. The method ofclaim 23, wherein tapping the first cross port comprises tapping asecond cross port in the adapter, and wherein the method furthercomprises: installing a retention rod through the second cross portafter landing the capillary hanger in the wellhead, and engaging an endof the retention rod in an external pocket on the capillary hanger. 25.The method of claim 23, wherein landing the capillary hanger in thewellhead comprises engaging seals on the capillary hanger above andbelow the side port with an inside bore of the wellhead.
 26. The methodof claim 23, wherein before attaching the capillary string to thecapillary hanger, the method comprises: landing the capillary hanger inthe wellhead without the capillary string; determining a length on anend of the capillary hanger to remove to align the side port on thecapillary hanger with the first cross port; removing the capillaryhanger; and removing the length of the distal end from the capillaryhanger.
 27. The method of claim 23, wherein before deploying the safetyvalve, the method comprises: installing a tubing hanger in a hanger bowlat the wellhead, installing an adapter on the hanger bowl and thehanger, and installing one or more components of a tree above theadapter.
 28. The method of claim 27, wherein tapping the first crossport in the wellhead comprises drilling the first cross port from anexterior of the adapter to a central bore of the adapter.
 29. The methodof claim 23, further comprising attaching a control line outside thewellhead to the first cross port, the control line communicating withthe capillary string via the first cross port at the wellhead and theside port in the capillary hanger.
 30. The method of claim 23, whereinattaching the capillary string to the capillary hanger comprisesconnecting the capillary string to a bottom port on the end of thecapillary hanger with a fitting, the bottom port communicating with theside port.
 31. A safety valve deployment apparatus, comprising: a tubinghanger installing in a hanger bowl at a wellhead; an adapter installingon the hanger bowl and having a bore engaging portion of the tubinghanger; a capillary hanger installing at least partially in the tubinghanger and the adapter, the capillary hanger having an internal port,the internal port having a first port end disposed on a distal end ofthe capillary hanger and having a second port end disposed on a sidewallof the capillary hanger, the first port end communicating with thecentral bore of the tubing hanger and coupleable to a capillary stringconnectable to a surface controlled subsurface safety valve installeddownhole, the second port end communicable with a first cross portdefined in the adapter from its exterior surface to the bore.
 32. Theapparatus of claim 31, further comprising first and second sealsdisposed on the sidewall of the capillary hanger above and below thesecond port end and engaging the bore of the adapter.
 33. The apparatusof claim 31, wherein the capillary hanger defines one or more passagescommunicating the distal end of the capillary hanger with a proximal endthereof.
 34. The apparatus of claim 31, wherein the capillary hangercomprises an external pocket defined in the sidewall and communicablewith a second cross port defined in the adapter from its exteriorsurface to the bore.
 35. The apparatus of claim 34, further comprising aretention rod disposable in the second cross port and insertable intothe external pocket of the capillary hanger.